Carbon Management Research in UKy -CAER

1. Carbon Management Research in UKy-CAER Rodney Andrews Center for Applied Energy Research University of Kentucky Supported by Carbon Management Research Group Kentucky EEC - DEDI ARPA-E US DOE International Collaboration US Department of Energy

2. Carbon Management Research Group • Build on E-ON US investment in carbon management project • Develop more energy and cost effective carbon management technologies • Address specific materials, controls and waste management solutions • Allow early adoption of technologies by Kentucky’s electric utilities • Current Founding Members: Five Utilities, EPRI and KY DEDI

3. Three Research Topics • Short-medium Term Projects • Post-Combustion CO2 Capture • 0.1MWth Pilot-scale study • 0.5~1MWth Slipstream field testing at members’ sites • Technical-Economic Analysis • Long-term Project • Chemical Looping Combustion/ Gasification for Solid Fuels

4. CAER Pilot-Plant Research Completed commissioning using K2CO3 Solvent Only reaches 3%-10% capture 100-hour Preliminary Study using K2CO3/Piperizane (PZ) Could reach 90% capture Precipitation of PZ Two-month MEA with 32 runs using ceramic packing MEA degradation vs. stripping temperature Mass transfer under utility flue gas conditions 1.5-year study using Aqueous Ammonia Ammonia slip vs. rich-solution pH etc Mass transfer/energy vs. packing and operating parameters Troubleshooting and problem solving On-going new solution study Catalyzed solvent Formulated solvent

5. Current Funding Mechanism • Kentucky Energy and Environment Cabinet • Carbon Management Research Industrial Members (AEP, Duke, Easy Ky Power, LG&E and KU, and EPRI) • APRA-E (three years) for post-scrubbing solution dewatering • DOE International Collaboration (five years) on catalyst development and CDI dewatering • DOE (four years) on slipstream-scale study on solvent-based post-combustion CO2 capture process

6. The History of Coal Fired Power Plant

7. CO2 Emission vs. Net Plant Efficiency (coal)

8. Do We Have to Pay for Separation • Targeted Process: • From a dilute state to over 90% purity • dStotal = dSsystem + dSsurrounding ≥ 0 • the entropy of an isolated system which is not in equilibrium will tend to increase over time, approaching a maximum value at equilibrium; • the entropy change dS of a system undergoing any infinitesimal reversible process is given by δq / T, where δq is the heat supplied to the system and T is the absolute temperature of the system.

9. The Minimum Work for Separation Only • The first law • The Second law from 14% to 90% 175 kJ/kg CO2 (166 Btu/kg CO2) ~4% of coal HHV

10. CO2 Management Approach

11. Post CO2 Capture Process • Challenges • Low CO2 concentration in flue gas • High direct compression cost • High transportation cost • CO2 Enrichment Process • High energy consumption (50-80% increasing in COE) • Finding appropriate technologies Clean gas (CO2<1%) CO2 Stream (>90%) Lean Sorbent Abs Reg Flue Gas (CO2 ~14%) Heat Rich Sorbent

12. IGCC PC Flue Gas CO2 Scrubbing Process Options

13. What does CCS COE Incremental Include?

14. Capital Investment: The Priorities The requirement of solvent is fast kinetic The requirement of solvent is to have higher net cyclic capacity Source:Vattenfall

15. Conflicts (Impact will be discussed later on)

16. Solvents Comparison

17. VLE -- for determining the solvent capacity and heat of absorption; Wetted Wall Column – for determining the reaction rate, the catalytic effect New Solvents Development

18. Mini-scrubber, scaleup from WWC, is used for solvent and catalyst development Pilot-plant for selected solvent and catalyst Mini-scrubber and Pilot-scale

19. The Need for CCS Heat Integration Heat Rejected (600 Btu/lb CO2) Heat Rejected (400 Btu/lb CO2) Heat rejected (100 Btu/lb CO2) Heat Rejected to CW (400 Btu/lb CO2) Heat needed (1300 Btu/lb CO2)

20. Can We Get fully Heat Integration? L/R EHX ΔT Has to reject by polish EHX Rich Solution FG Dew Point Temp-limited Stripper Condenser Some, ALL?? Yes, but little Combustion Air FW Heating FG Temp Profile Else?? Steam extraction

21. What We Have Proposed for DOE Slipstream Project 2. Engineering design, build and install an advanced CO2 capture system into an existing PC power plant at a 0.7 MWe slipstream scale (~15 TPD CO2) Three novel processes will be designed and integrated: 2-stage solvent striping, cooling tower desiccant, and Hitachi solvent 1. 3. • 1. Two-stage Stripping: • Increase solvent working capacity by providing a secondary air-stripping column following • the conventional steam stripping column. • Air stripping stream sent to boiler as combustion air to increase flue gas PCO2 exiting boiler • 2. Integrated Cooling Tower: • Use regenerated CO2 stream waste heat to dry liquid desiccant • Liquid desiccant is used to dry cooling tower air  Improved power plant cooling tower and • steam turbine efficiency • 3. Advanced Hitachi Solvent: • Primary amine analogous to MEA

22. Team Structure

23. What will We Do? • The design, start-up/commissioning of a 2MWth test facility (1400cfm); • Two proprietary solvents are to be tested for parametric investigation and long-term verification; • New corrosion resistance coatings for material used in CCS system (access ports needed in scrubber and stripper areas) • Solvent degradation (liquid product and gaseous emissions from CCS) • A series of transient tests to quantify the ability of the carbon capture system to follow load demand.

24. Preliminary 3-D View of Slipstream Unit • 80 ft tall • 1000 ft2footprint • (15’x65’, but could be rearranged) • 5 to 6 modulus with 100,000lbs/modulus • Plus control/lab trailer and others

25. Testing Site: LG&E and KU’s Brown Generating Station